Operating Agreement (Joint Operating Agreement)

What Is an Operating Agreement?

Operating agreement (also called a joint operating agreement, or JOA) is a contract among co-owners of oil and gas working interests in a jointly developed property that designates one party as the operator, establishes each party's proportionate share of costs and revenues (working interest percentage), defines decision-making authority and voting thresholds for major operations, and governs the financial and operational relationship between the working interest owners throughout the life of the property. The JOA is the foundational governance document for any jointly held leasehold and remains in force from initial development through abandonment.

Key Takeaways

A JOA designates one party as the operator with authority to conduct all field operations on behalf of the working interest owners, subject to AFE approval thresholds.
The AAPL Form 610 is the dominant standardized JOA template in the United States, with state-specific supplements addressing local regulatory and property law requirements.
Non-consent elections allow a working interest owner to decline participation in a proposed operation; the penalty is forfeiture of a multiple of their share of costs (typically 300-500%) before receiving any revenue from that operation.
Cash call provisions require non-operating working interest owners to fund their proportionate share of costs in advance of expenditure, typically within 15-30 days of the operator's request.
Preferential purchase rights and area of mutual interest (AMI) clauses govern how working interests may be transferred and how new acreage acquisitions within a defined area are shared among the parties.

How an Operating Agreement Works

When two or more parties hold working interests in the same oil and gas lease or unit, they execute a JOA to establish how the joint property will be operated and how costs and revenues will be shared. The agreement designates one party, the operator, to conduct all day-to-day field operations: drilling, completions, production operations, regulatory compliance, accounting, and reporting. The operator acts as an agent on behalf of all working interest owners and is generally entitled to overhead charges (a fixed percentage of direct costs) as compensation. Non-operating working interest owners (non-ops) have no authority to direct field operations independently but retain important rights: access to records, audit rights, the right to take their share of production in kind, and voting rights on major expenditures above defined thresholds.

Financial governance centers on the authorization for expenditure (AFE) process. Before committing to any major expenditure, typically defined as any operation costing above a threshold set in the JOA (often $50,000 to $250,000 depending on field size), the operator circulates an AFE among non-operating parties. The AFE describes the proposed operation, the estimated cost breakdown, and the deadline for election. Working interest owners who approve the AFE commit to fund their proportionate share. Owners who decline are making a non-consent election, with significant financial consequences under most JOAs. The operator proceeds once sufficient working interest has approved, typically requiring either majority approval or the operator's own participation if other thresholds are not met.

Fast Facts: Operating Agreement

Standard form: AAPL Form 610 (American Association of Professional Landmen), most recent revision 1989; widely used with state-specific amendments
Non-consent penalty: typically 300-500% of the non-consenting party's share of costs before payout from that specific operation
Cash call timing: non-operators generally must fund their share within 15-30 days of the operator's written request
Operator overhead: typically 10-15% of direct field costs, specified in the Accounting Procedure exhibit attached to the JOA
Voting threshold: most JOAs require approval from parties holding more than 50% of working interest; supermajority thresholds apply to abandonment and other major decisions
AFE overrun allowance: operator typically allowed 10-15% cost overrun before required to seek new approval from non-operators
Preferential right period: typically 15-30 days for existing parties to exercise their right to acquire a transferring party's interest
Governing law: typically the state where the majority of the acreage is located; Canadian JOAs typically governed by CAPL Operating Procedure

Field Tip:

Read the non-consent penalty clause carefully before signing any JOA. A 500% non-consent penalty means that if you decline to participate in a $1 million well and the well is successful, you must pay $500,000 in penalties to the consenting parties before you receive a single dollar of revenue from your interest in that well. Many smaller working interest owners have been effectively wiped out by accepting working interests in JOAs with punitive non-consent provisions on high-cost offshore or deepwater operations. Always model the penalty scenario before electing non-consent on any major capital operation.

Operator Designation, Duties, and Removal

The operator designation is one of the most important provisions of any JOA. The operator controls the pace of development, the selection of contractors and service companies, the timing of operations, and the quality of record-keeping and environmental compliance. Most JOAs provide that the operator serves at the pleasure of the working interest owners: a supermajority (often parties holding more than 75% of working interest) can vote to remove and replace the operator if the operator fails to conduct operations in a workmanlike manner, becomes insolvent, or is convicted of a crime related to the property. In practice, operator removal is rare and contentious because it requires transferring all operational records, contracts, regulatory permits, and field personnel to the replacement operator. The departing operator is typically entitled to reimbursement of reasonable transition costs and settlement of any outstanding accounts payable or receivable under the joint account.

The non-consent mechanism gives each working interest owner the right to decline participation in any proposed operation, including new wells, workovers, recompletions, and secondary recovery projects. A non-consenting party does not fund its share of costs for that operation but also does not receive revenue until the consenting parties have recovered their costs plus the non-consent penalty multiple. Penalty multiples of 300-400% are common for development wells, while exploratory wells may carry penalties of 400-500% to compensate consenting parties for taking on additional geological risk alone. The non-consent provision allows smaller working interest owners to manage their capital exposure in active fields where the operator proposes drilling multiple wells per year.

Area of mutual interest (AMI) clauses bind the parties to share any new lease acquisitions within a defined geographic area, typically a specific township, county, or acreage block around the joint property. If one party acquires acreage within the AMI, it must offer each other JOA party the right to participate in that acquisition at the same proportionate cost. AMI clauses prevent one party from quietly leasing up acreage surrounding the joint property and then developing it independently, which would be adverse to the other parties' interests. AMI provisions must define geographic boundaries precisely, specify duration (often 3-5 years or for the life of the JOA), and state whether they cover only oil and gas leases or also include mineral purchases, royalty acquisitions, and overriding royalty interests.

joint operating agreement (JOA): the full formal name; "operating agreement" and "JOA" are used interchangeably throughout the industry
CAPL Operating Procedure: the Canadian equivalent standard form, published by the Canadian Association of Petroleum Landmen, analogous to AAPL Form 610
authorization for expenditure (AFE): the budget approval document circulated by the operator before any major expenditure, requiring non-operator sign-off
non-consent penalty: the cost multiple (typically 300-500%) that a non-consenting working interest owner must repay to consenting parties before receiving revenue from a non-consented operation

Frequently Asked Questions About Operating Agreements

What happens when working interest owners disagree about whether to abandon a well?

Most JOAs contain specific provisions governing abandonment. A party wishing to abandon a non-producing well typically must provide written notice to all other parties and allow them a defined period (often 30-60 days) to take over the well at their own cost and risk. If no other party elects to take over, the abandonment proceeds and costs are shared in proportion to working interest. If one party takes over the well, it does so subject to the obligation to properly abandon the well eventually and indemnify the abandoning parties from future liability. Disputes over premature abandonment versus continued attempts at production are among the most contentious issues that arise under JOAs, particularly in marginally economic fields late in their producing life.

How does the cash call process work in practice?

The operator prepares a monthly or bi-monthly joint interest billing (JIB) statement that details all expenditures charged to the joint account during the billing period, allocated among the working interest owners in proportion to their respective interests. Separately, the operator may issue advance cash calls before large expenditures to ensure funds are in the joint account before costs are incurred. Non-operators who fail to pay within the specified period (typically 15-30 days) are typically assessed interest on unpaid balances and may lose their right to participate in subsequent operations as a defaulting party. Repeated or material defaults can trigger operator enforcement remedies that range from withholding the defaulting party's production revenue to initiating legal proceedings for recovery of the unpaid share.

Are operating agreements required by law or are they purely contractual?

JOAs are purely contractual instruments; no law requires co-owners of working interests to execute one. However, operating without a JOA in a multi-party working interest arrangement creates serious practical problems: there is no agreed mechanism for cost allocation, no designated operator with authority to sign regulatory permits and contracts, and no procedure for resolving disputes between co-owners. Most lenders financing oil and gas development require JOAs to be in place before funding, and many state oil and gas regulatory agencies require identification of an operator of record before approving permits. In practice, virtually every multi-party working interest arrangement operates under a JOA or equivalent contractual framework.

Why Operating Agreements Matter in Oil and Gas

The joint operating agreement is the legal backbone of co-owned oil and gas development. Without a JOA, disputes over operational authority, cost sharing, revenue distribution, and abandonment obligations would have no contractual resolution framework, leaving parties to rely entirely on statutory co-tenancy law, which is ill-suited to the practical realities of oil and gas operations. For landmen and petroleum attorneys, drafting and negotiating JOAs is a core daily function. For working interest owners, understanding JOA provisions, particularly non-consent penalties, cash call obligations, and preferential purchase rights, is essential to managing capital exposure and protecting their economic interests across the producing life of the property. For operators, the JOA defines the scope of their authority and their fiduciary-like duty to conduct operations in a workmanlike manner for the benefit of all co-owners, which is the standard by which their performance is measured in any dispute.